Henry Hub natural gas futures drifted lower in mid-October, with the NYMEX November contract trading at $3.119 per mmBtu after settling at $3.169 in the prior session. The move left the market just above its 200-day exponential moving average near $3.09, a closely watched level as traders assess whether prices will stabilize or test the $3.00 floor.
The main pressure point is weather. Forecasts continue to show above-normal temperatures across key heating regions of the United States, delaying the seasonal rise in residential and commercial gas demand. That demand weakness has outweighed a sharp drop in Lower 48 production to about 107.1 Bcf/d, an eight-month low.
For investors, the tension is clear: warm weather is bearish in the short term, but below-normal storage injections, regional tightness in the Gulf Coast, and strong LNG demand are preventing a deeper selloff in Henry Hub natural gas.
Key Facts
- The NYMEX November natural gas contract traded at $3.119 per mmBtu, down 5 cents from the prior settlement of $3.169.
- Lower 48 gas production fell from a record 113.3 Bcf/d to roughly 107.1 Bcf/d, marking an eight-month low.
- U.S. working gas in storage stood at 3,500 Bcf, which was 68 Bcf above the five-year average and 130 Bcf below the year-ago level.
- Forecasts for the week ahead assign up to an 80% probability of above-normal temperatures across the north-central United States.
- Gas flows to major U.S. LNG export plants averaged about 17.4 Bcf/d in October, below the April record of 18.8 Bcf/d.
Henry Hub natural gas
Henry Hub natural gas is trading in a narrow but important range because domestic fundamentals are pulling prices in opposite directions. On one side, weather models point to a slower start for winter heating demand. Heating degree day forecasts remain below long-term norms, and that matters most in October, when small changes in temperature expectations can sharply alter storage trajectories and front-month pricing.
On the other side, supply has tightened. Production has fallen meaningfully from late-summer records, and storage injections have run below seasonal norms for eight straight weeks. That combination has steadily reduced the storage surplus versus the five-year average. Even with inventories still slightly above normal nationally, the market has become less comfortable than headline totals suggest.
The result is a market that remains domestically driven despite much higher gas prices overseas. European and Asian benchmarks are trading far above Henry Hub, but U.S. LNG export capacity is already close to full utilization. Until additional liquefaction capacity starts up, global price spikes can improve exporter margins without immediately pulling much more gas out of the domestic market. For now, Henry Hub remains more sensitive to U.S. weather, storage reports, and regional supply conditions than to international benchmarks.
Warm weather is setting the short-term tone, but tighter supply and smaller storage builds are keeping Henry Hub from breaking decisively below $3.
Why the $3.09 level matters
Technical support near $3.09 has become a key reference point because it aligns with the 200-day exponential moving average and sits just above the psychologically important $3.00 mark. A daily close below that area would likely reinforce bearish momentum and shift attention toward whether injections begin rebuilding the storage surplus.
Upside resistance remains around $3.30 to $3.40, a zone the November contract has struggled to clear during October. For bulls, a colder weather turn, a smaller-than-expected storage injection, or a faster rebound in LNG feedgas demand would be needed to push prices back toward that range.
Implications for Investors
For energy investors, the current setup argues for caution rather than conviction. In the near term, futures remain vulnerable to additional pressure if mild weather persists through late October and production normalizes after storm-related and pipeline-related disruptions. A storage build above expectations could quickly test support near $3.09 and potentially $3.00.
At the same time, the downside is not unlimited. South Central storage remains tighter than national figures imply, with inventories in that region below seasonal norms and salt cavern stocks notably constrained. Because Henry Hub is directly tied to Gulf Coast demand centers, including LNG export facilities and petrochemical consumption, regional tightness can help support benchmark prices even when Northeast and Appalachian spot markets weaken sharply.
Longer term, investors should watch three variables closely: the pace of production recovery toward 112 to 113 Bcf/d, the timing of new LNG export capacity, and the first durable shift in November weather models. If output rebounds while temperatures stay mild, the market could struggle to rally. If colder patterns emerge just as LNG demand strengthens and storage surpluses narrow further, Henry Hub could move higher quickly into the winter contract roll.
The next major catalyst is the weekly storage report, with expectations centered around a 74 Bcf to 77 Bcf injection. A softer build would reinforce the tightening narrative, while a larger injection would strengthen the case that warm weather is still firmly in control of the market.